Catwalk System

ABSTRACT

A catwalk system comprising a catwalk suitcase and a tubular handling catwalk. The catwalk suitcase may have a base configured to receive the tubular handling catwalk, and a ramp connected with the base and configured to extend diagonally to a drill rig floor located at an oil and gas wellsite. The ramp may be configured to facilitate movement of tubulars from the tubular handling catwalk to the drill rig floor.

BACKGROUND OF THE DISCLOSURE

Wells are generally drilled into the ground or ocean bed to recovernatural deposits of oil, gas, and other materials that are trapped insubterranean formations. Well construction operations (e.g., drillingoperations) may be performed at a wellsite by a drilling system (e.g., adrilling rig) having various automated surface and subterraneanequipment operating in a coordinated manner. For example, a drivemechanism, such as a top drive or rotary table located at a wellsitesurface can be utilized to rotate and advance a drill string into asubterranean formation to drill a wellbore. The drill string may includea plurality of drill pipes coupled together and terminating with a drillbit. Length of the drill string may be increased by adding additionaldrill pipes while depth of the wellbore increases. Drilling fluid may bepumped from the wellsite surface down through the drill string to thedrill bit. The drilling fluid lubricates and cools the drill bit, andcarries drill cuttings from the wellbore back to the wellsite surface.The drilling fluid returning to the surface may then be cleaned andagain pumped through the drill string. The equipment of the drillingsystem may be grouped into various subsystems, wherein each subsystemperforms a different operation controlled by a corresponding localand/or a remotely located controller.

A tubular handling machine, such as a catwalk, may convey tubularsbetween a rig floor of the drilling system and a tubular storage area,which may be located at a ground level of the wellsite below the rigfloor. When a catwalk has to be replaced with another catwalk, such asto accommodate different tubulars to be transferred to the rig floor,the catwalk has to be replaced expeditiously to resume the drillingand/or other wellsite operations. Also, when a catwalk breaks down,tubulars cannot be transferred to the rig floor, thereby bringingdrilling and/or other wellsite operations to a standstill. If thecatwalk cannot be repaired expeditiously onsite, the catwalk will alsohave to be replaced. However, disassembly, removal, and installation ofa replacement catwalk can take an extended period of time (e.g., severalhours, a full day, or longer).

SUMMARY OF THE DISCLOSURE

This summary is provided to introduce a selection of concepts that arefurther described below in the detailed description. This summary is notintended to identify indispensable features of the claimed subjectmatter, nor is it intended for use as an aid in limiting the scope ofthe claimed subject matter.

The present disclosure introduces an apparatus including a base and aramp. The base receives a tubular handling catwalk. The ramp isconnected with the base and extends diagonally to a drill rig floorlocated at an oil and gas wellsite. The ramp facilitates movement oftubulars from the tubular handling catwalk to the drill rig floor.

The present disclosure also introduces an apparatus including a catwalksuitcase that includes a base, a ramp, and fluid conduits. The basedetachably connects with a tubular handling catwalk. The ramp isconnected with the base and extends to a drill rig floor located at anoil and gas wellsite. The ramp facilitates movement of tubulars from thetubular handling catwalk to the drill rig floor. The fluid conduits areconnected with and extend along the base and/or ramp.

The present disclosure also introduces a method that includes installinga catwalk suitcase at an oil and gas wellsite such that a base of thecatwalk suitcase is disposed at a ground level of the oil and gaswellsite and a ramp of the catwalk suitcase extends to a rig floor of adrill rig. The method also includes detachably connecting a tubularhandling catwalk with the base and moving tubulars from the tubularhandling catwalk to the rig floor via the ramp.

These and additional aspects of the present disclosure are set forth inthe description that follows, and/or may be learned by a person havingordinary skill in the art by reading the material herein and/orpracticing the principles described herein. At least some aspects of thepresent disclosure may be achieved via means recited in the attachedclaims.

BRIEF DESCRIPTION OF THE DRAWINGS

The present disclosure is understood from the following detaileddescription when read with the accompanying figures. It is emphasizedthat, in accordance with the standard practice in the industry, variousfeatures are not drawn to scale. In fact, the dimensions of the variousfeatures may be arbitrarily increased or reduced for clarity ofdiscussion.

FIG. 1 is a schematic view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIG. 2 is a schematic view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIG. 3 is a schematic side view of at least a portion of an exampleimplementation of apparatus according to one or more aspects of thepresent disclosure.

FIG. 4 is a side view of the apparatus shown in FIG. 3 in a differentstage of operations according to one or more aspects of the presentdisclosure.

FIG. 5 is a side view of at least a portion of the apparatus shown inFIG. 4 in a different stage of operations according to one or moreaspects of the present disclosure.

FIG. 6 is a top view of the apparatus shown in FIG. 4 according to oneor more aspects of the present disclosure.

FIG. 7 is a bottom view of the apparatus shown in FIG. 4 according toone or more aspects of the present disclosure.

FIG. 8 is a front view of the apparatus shown in FIG. 4 according to oneor more aspects of the present disclosure.

FIG. 9 is a back view of the apparatus shown in FIG. 4 according to oneor more aspects of the present disclosure.

DETAILED DESCRIPTION

It is to be understood that the following disclosure provides manydifferent embodiments, or examples, for implementing different featuresof various embodiments. Specific examples of components and arrangementsare described below to simplify the present disclosure. These are, ofcourse, merely examples and are not intended to be limiting. Inaddition, the present disclosure may repeat reference numerals and/orletters in the various examples. This repetition is for simplicity andclarity, and does not in itself dictate a relationship between thevarious embodiments and/or configurations discussed.

Systems and methods (e.g., processes, operations) according to one ormore aspects of the present disclosure may be utilized or otherwiseimplemented in association with an automated well construction system(e.g., a drilling rig) at an oil and gas wellsite, such as forconstructing a wellbore to obtain hydrocarbons (e.g., oil and/or gas)from a subterranean formation. However, one or more aspects of thepresent disclosure may be utilized or otherwise implemented inassociation with other automated systems in the oil and gas industry andother industries. For example, one or more aspects of the presentdisclosure may be implemented in association with wellsite systems forperforming fracturing, cementing, acidizing, chemical injecting, and/orwater jet cutting operations, among other examples. One or more aspectsof the present disclosure may also be implemented in association withmining sites, building construction sites, and/or other work sites whereautomated machines or equipment are utilized.

FIG. 1 is a schematic view of at least a portion of an exampleimplementation of a well construction system 100 according to one ormore aspects of the present disclosure. The well construction system 100represents an example environment in which one or more aspects of thepresent disclosure described below may be implemented.

The well construction system 100, which may be or comprise a drillingrig, is depicted in relation to a wellbore 102 formed by rotary and/ordirectional drilling from a wellsite surface 104 and extending into asubterranean formation 106. The well construction system 100 includessurface equipment 110 located at the wellsite surface 104 and a drillstring 120 suspended within the wellbore 102. The surface equipment 110may include a mast, a derrick, and/or another support structure 112disposed over a rig floor 114. The drill string 120 may be suspendedwithin the wellbore 102 from the support structure 112. The supportstructure 112 and the rig floor 114 may be collectively supported overthe wellbore 102 above the ground level of the wellsite surface 104 bylegs and/or other support structures (not shown).

The drill string 120 may comprise a bottom-hole assembly (BHA) 124 andmeans 122 for conveying the BHA 124 within the wellbore 102. Theconveyance means 122 may comprise drill pipe, heavy-weight drill pipe(HWDP), wired drill pipe (WDP), tough logging condition (TLC) pipe,coiled tubing, and/or other means for conveying the BHA 124 within thewellbore 102. A downhole end of the BHA 124 may include or be coupled toa drill bit 126. Rotation of the drill bit 126 and the weight of thedrill string 120 collectively operate to form the wellbore 102. Thedrill bit 126 may be rotated from the wellsite surface 104 and/or via adownhole mud motor (not shown) connected with the drill bit 126.

The support structure 112 may support a driver, such as a top drive 116,operable to connect (perhaps indirectly) with an uphole end of theconveyance means 122, and to impart rotary motion 117 and verticalmotion 135 to the drill string 120 and the drill bit 126. However,another driver, such as a kelly and rotary table (neither shown), may beutilized instead of or in addition to the top drive 116 to impart therotary motion 117. The top drive 116 and the connected drill string 120may be suspended from the support structure 112 via hoisting equipment,which may include a traveling block 118, a crown block (not shown), anda draw works 119 storing a support cable or line 123. The crown blockmay be connected to or otherwise supported by the support structure 112,and the traveling block 118 may be coupled with the top drive 116, suchas via a hook. The draw works 119 may be mounted on or otherwisesupported by the rig floor 114. The crown block and traveling block 118comprise pulleys or sheaves around which the support line 123 is reevedto operatively connect the crown block, the traveling block 118, and thedraw works 119 (and perhaps an anchor). The draw works 119 may thusselectively impart tension to the support line 123 to lift and lower thetop drive 116, resulting in the vertical motion 135. The draw works 119may comprise a drum, a frame, and a prime mover (e.g., an engine ormotor) (not shown) operable to drive the drum to rotate and reel in thesupport line 123, causing the traveling block 118 and the top drive 116to move upward. The draw works 119 may be operable to release thesupport line 123 via a controlled rotation of the drum, causing thetraveling block 118 and the top drive 116 to move downward.

The top drive 116 may comprise a grabber, a swivel (neither shown), atubular handling assembly links 127 terminating with an elevator 129,and a drive shaft 125 operatively connected with a prime mover (notshown), such as via a gear box or transmission (not shown). The drillstring 120 may be mechanically coupled to the drive shaft 125 with orwithout a sub saver between the drill string 120 and the drive shaft125. The prime mover may be selectively operated to rotate the driveshaft 125 and the drill string 120 coupled with the drive shaft 125.Hence, during drilling operations, the top drive 116 in conjunction withoperation of the draw works 119 may advance the drill string 120 intothe formation 106 to form the wellbore 102. The tubular handlingassembly links 127 and the elevator 129 of the top drive 116 may handletubulars (e.g., drill pipes, drill collars, downhole tools, casingjoints, etc.) that are not mechanically coupled to the drive shaft 125.For example, when the drill string 120 is being tripped into or out ofthe wellbore 102, the elevator 129 may grasp individual tubulars andtubulars forming the drill string 120 such that the individual tubularsand the drill string can be raised and/or lowered via the hoistingequipment mechanically coupled to the top drive 116. The grabber mayinclude a clamp that clamps onto a tubular when making up and/orbreaking out a connection of a tubular with the drive shaft 125.

The well construction system 100 may further include a well controlsystem for maintaining well pressure control. For example, the drillstring 120 may be conveyed within the wellbore 102 through variousblowout preventer (BOP) equipment disposed at the wellsite surface 104on top of the wellbore 102 and perhaps below the rig floor 114. The BOPequipment may be operable to control pressure within the wellbore 102via a series of pressure barriers (e.g., rams) between the wellbore 102and the wellsite surface 104. The BOP equipment may include a BOP stack130, an annular preventer 132, and/or a rotating control device (RCD)138 mounted above the annular preventer 132. The BOP equipment 130, 132,138 may be mounted on top of a wellhead 134.

The well construction system 100 may further include a drilling fluidcirculation system operable to circulate fluids between the surfaceequipment 110 and the drill bit 126 during drilling and otheroperations. For example, the drilling fluid circulation system may beoperable to inject a drilling fluid from the wellsite surface 104 intothe wellbore 102 via an internal fluid passage 121 extendinglongitudinally through the drill string 120. The drilling fluidcirculation system may comprise a pit, a tank, and/or another fluidcontainer 142 (e.g., a mud pit, a suction tank) holding the drillingfluid (i.e., mud) 140, and a pump 144 operable to move the drillingfluid 140 from the container 142 into the fluid passage 121 of the drillstring 120 via a fluid conduit 146 extending from the pump 144 to thetop drive 116 and an internal passage extending through the top drive116. The fluid conduit 146 may comprise one or more of a pump dischargeline, a stand pipe, a rotary hose, and a gooseneck (not shown) connectedwith a fluid inlet of the top drive 116. The pump 144 and the container142 may be fluidly connected by a fluid conduit 148, such as a suctionline.

During drilling operations, the drilling fluid may continue to flowdownhole through the internal passage 121 of the drill string 120, asindicated by directional arrow 158. The drilling fluid may exit the BHA124 via ports 128 in the drill bit 126 and then circulate uphole throughan annular space 108 (“annulus”) of the wellbore 102 defined between anexterior of the drill string 120 and the wall of the wellbore 102, suchflow being indicated by directional arrows 159. In this manner, thedrilling fluid lubricates the drill bit 126 and carries formationcuttings uphole to the wellsite surface 104. The returning drillingfluid may exit the annulus 108 via a bell nipple 139, an RCD 138, and/ora ported adapter 136 (e.g., a spool, a wing valve, etc.) located belowone or more portions of the BOP stack 130.

The drilling fluid exiting the annulus 108 via the bell nipple 139 maybe directed toward drilling fluid reconditioning equipment 170 via afluid conduit 145 (e.g., a gravity return line) to be cleaned and/orreconditioned, as described below, prior to being returned to thecontainer 142 for recirculation. The drilling fluid exiting the annulus108 via the RCD 138 may be directed into a fluid conduit 160 (e.g., adrilling pressure control line), and may pass through various wellsiteequipment fluidly connected along the conduit 160 prior to beingreturned to the container 142 for recirculation. For example, thedrilling fluid may pass through a choke manifold 162 (e.g., a drillingpressure control choke manifold) and then through the drilling fluidreconditioning equipment 170. The choke manifold 162 may include atleast one choke and a plurality of fluid valves (neither shown)collectively operable to control the flow through and out of the chokemanifold 162. Backpressure may be applied to the annulus 108 by variablyrestricting flow of the drilling fluid or other fluids flowing throughthe choke manifold 162. The greater the restriction to flow through thechoke manifold 162, the greater the backpressure applied to the annulus108. The drilling fluid exiting the annulus 108 via the ported adapter136 may be directed into a fluid conduit 164 (e.g., a rig choke line),and may pass through various equipment fluidly connected along theconduit 164 prior to being returned to the container 142 forrecirculation. For example, the drilling fluid may pass through a chokemanifold 168 (e.g., a rig choke manifold, well control choke manifold)and then through the drilling fluid reconditioning equipment 170. Thechoke manifold 168 may include at least one choke and a plurality offluid valves (neither shown) collectively operable to control the flowthrough the choke manifold 168. Backpressure may be applied to theannulus 108 by variably restricting flow of the drilling fluid or otherfluids flowing through the choke manifold 168.

Before being returned to the container 142, the drilling fluid returningto the wellsite surface 104 may be cleaned and/or reconditioned viadrilling fluid reconditioning equipment 170, which may include one ormore of liquid gas separators (e.g., a poor boy separator 171), shaleshakers 172, centrifuges, and other drilling fluid cleaning,reconditioning, and/or other processing equipment 173. The liquid gasseparators may remove mud gasses entrained in the drilling fluiddischarged from the wellbore 102 and the shale shakers 172 may separateand remove solid particles 141 (e.g., drill cuttings) from the drillingfluid into a solids container 143 (e.g., a reserve pit). The drillingfluid reconditioning equipment 170 may further comprise equipment 173operable to remove additional gas and finer formation cuttings from thedrilling fluid and/or modify physical properties or characteristics(e.g., rheology) of the drilling fluid. For example, the drilling fluidreconditioning equipment 170 may include a degasser, a desander, adesilter, a mud cleaner, and/or a decanter, among other examples.Intermediate tanks/containers (not shown) may be utilized to hold thedrilling fluid while the drilling fluid progresses through the variousstages or portions of the drilling fluid reconditioning equipment 170.The cleaned/reconditioned drilling fluid may be transferred to the fluidcontainer 142, the solid particles 141 removed from the drilling fluidmay be transferred to the solids container 143, and/or the gas removedfrom the drilling fluid may be transferred to a flare stack 174 via aconduit 175 (e.g., a flare line) to be burned or to a container (notshown) for storage and removal from the wellsite.

Throughout different regions (e.g., the Middle East) cement pumps,tanks, and related equipment are commonly located about thirty meters ormore away from well center. During a cement job, wellsite operators mayinstall high-pressure jumper hoses between cement piping connections atan outer end of a catwalk and cement pumps. The wellsite operators mayalso install a hose, manifolds, and other equipment between the wellcenter and the end of the cement piping along a catwalk ramp. Cement maythen be pumped from the cement tanks, along the temporary hose on theground, to the installed cement piping in the catwalk, throughhigh-pressure swivel joints to the ramp (V-Door) section of the piping,then through the temporary hose and other equipment on the drill floorto the well center.

In a well control situation, normal pressure may be supplied from therig mud pumps via permanently installed kill lines. Rig mud pumps arecapable of generating between about 5,000 PSI and about 7,500 PSI,depending on the rig. However, well control pressure can reach pressuresof up to about 15,000 PSI. In a well control event, where trappedpressure is greater than the pressure the rig mud pumps can generate, acement pump may be used to kill the well. Such method may be known as an“emergency kill.” Cement pumps may normally generate pressures rangingbetween about 10,000 PSI and about 15,000 PSI. Because the cement pumpsare located at such distances from the well center, a high-pressure killhose may be temporarily installed between the cement pumps and the killpiping installed in the catwalk. A permanently installed high-pressurekill hose may extend from the rig end of the catwalk frame to a wellBOP. The high-pressure kill hoses and the kill piping in the catwalkoperate as the kill path for mud that is pumped by the cement pumps.

High-pressure hoses and piping, such as the high-pressure kill hoses andpiping, are expensive and require re-certification and maintenanceregardless of whether such hoses and piping are used. Furthermore,safety regulations mandate that high-pressure hoses and piping, andtheir connections, undergo pressure testing each time such high-pressurehoses and piping are disconnected. Furthermore, catwalks may be “shared”or swapped between different rigs. Some rigs may normally utilize manualor conventional catwalk and ramp systems. A hydraulic catwalk may beinstalled for special or otherwise selected operations. Also, ahydraulic catwalk may be uninstalled for maintenance and replaced with amanual catwalk. Because of regulations that mandate that piping isinstalled in the catwalk and ramp, wellsite operators maintain at leasttwo sets of piping at the wellsite. The wellsite operators also takeseveral hours to disconnect the original piping, reconnect the next set,and then pressure test the entire system.

The present disclosure is directed to an example implementation of acatwalk system comprising a ramp and base system that compriseshigh-pressure piping and is detachably connectable with a catwalk, whichcan be swapped out without having to disconnect the high-pressurepiping. The catwalk system may, thus, permit having one set of piping atthe wellsite, reduce installation time, and facilitate installation ofanother catwalk without having to reconnect and pressure test thepiping.

FIG. 2 is a schematic view of an example implementation of a wellconstruction system 200 (e.g., a drilling rig) comprising a tubularhandling catwalk system 202 according to one or more aspects of thepresent disclosure. The well construction system 200 may comprise one ormore features of the well construction system 100 shown in FIG. 1,including where indicated by the same numerals. The well constructionsystem 200 may also be operable to perform processes of the wellconstruction system 100. Accordingly, the following description refersto FIGS. 1 and 2, collectively.

The catwalk system 202 may be or comprise tubular handling equipmentcollectively operable to convey tubulars 201 (e.g., drill pipes, drillcollars, casing joints, downhole tools, etc.) from the ground or groundlevel of the wellsite surface 104, to the rig floor 114, permitting thetubular handling assembly links 127 to grab and lift the tubulars 201above the wellbore 102 for connection with previously deployed tubulars.The catwalk system 202 may have a horizontal portion and an inclinedportion that extends between the horizontal portion and the rig floor114. The catwalk system 202 may comprise a tubular handling catwalk 206having a skate 221 movable along a channel or groove (not shown)extending longitudinally along the catwalk 206. The skate 221 may beoperable to convey (e.g., push) the tubulars 201 to the rig floor 114.The skate 221 may be driven along the groove by a drive system (notshown), such as a pulley system or a hydraulic system. The catwalksystem 202 may comprise one or more racks (not shown) configured tostore and/or transfer the tubulars 201 to the catwalk 206.

The catwalk system 202 may comprise a catwalk suitcase 204 configured tosupport, connect with, or otherwise receive the tubular handling catwalk206. The catwalk suitcase 204 may comprise a base 208 configured to bemounded or otherwise disposed at the ground level (e.g., on the ground)of the oil and gas wellsite 104 and to receive the catwalk 206. The base208 may be configured to detachably connect with the tubular handlingcatwalk 206 received by the base 208. The base 208 may also or insteadbe configured to support the catwalk 206 thereon above the ground levelof the oil and gas wellsite 104. The base 208 may be configured toreceive one at a time a different tubular handling catwalk 206 (e.g., amanual catwalk, a hydraulically powered catwalk, an electrically poweredcatwalk, etc.) and to permit the received catwalk 206 to be swapped orreplaced by another tubular handling catwalk 206. The received catwalk206 may be replaced by a different catwalk 206 based on, for example,wellsite operations or type of tubulars 201 that are intended to bemoved to or from the rig floor 114. The received catwalk 206 may also orinstead be replaced by a different tubular handling catwalk 206 when thereceived catwalk 206 breaks down. Accordingly, the tubular handlingcatwalk 206 is a selected one of a plurality of tubular handlingcatwalks 206. The catwalk suitcase 204 may further comprise a ramp 210(also known as a V-Door) connected with the base 208 and positioned inan inclined fashion (e.g., extending diagonally) between the base 208and the rig floor 114 at the oil and gas wellsite 104. When the catwalk206 is received by the base 208, the ramp 210 may facilitate movement ofthe tubulars 201 from the catwalk 206 to the rig floor 114.

The base 208 may comprise a horizontal portion 214 configured to bedisposed on and extending substantially parallel to the ground level(e.g., the ground) of the oil and gas wellsite 104, and a verticalportion 216 connected with the horizontal portion 214 and extendingsubstantially perpendicularly with respect to the ground level of theoil and gas wellsite 104. The ramp 210 may be pivotably connected withbase 208 via a pivot joint 220 at an upper end of the vertical portion216. The horizontal and vertical portions 214, 216 may define a space218 configured to receive the catwalk 206 therein. When the catwalk 206is received by the base 208 within the space 218, a powered skate 221 ofthe catwalk 206 can push the tubular 201 longitudinally along thecatwalk 206 toward the ramp 210. After the tubular 201 contacts a lowerportion of the ramp 210, the skate 221 may push the tubular 201 alongthe ramp 210 toward the rig floor 114 until an upper end (e.g., box end)of the tubular 201 extends above the rig floor 114.

The catwalk suitcase 204 may further comprise a plurality of fluidconduits 222, 224 extending longitudinally along at least a portion ofthe catwalk suitcase 204. The fluid conduits 222, 224 may extendlongitudinally along the base 208 and/or ramp 210 between opposing endsof the base 208 and/or ramp 210. The fluid conduits 222, 224 maytransfer or deliver to the wellbore 102 and/or the rig floor 114 one ormore utilities that are utilized during operations of the wellconstruction system 200.

One or more of the fluid conduits 222 may form at least a portion of thebase 208, extending between a distal end of the base 208 away from therig floor 114 and/or the wellbore 102 and a proximal end of the base 208closest to the rig floor 114 and/or the wellbore 102. One or more of thefluid conduits 222 may terminate with a distal fluid coupler 226 and anopposing proximal fluid coupler 228. The fluid conduits 222 and couplers226, 228 may be or comprise medium pressure (e.g., rated for 7,500 PSIor more) fluid conduits and couplers configured to convey kill weightfluid or other high density fluid to the annulus 108 of the wellbore 102during well kill operations at the oil and gas wellsite 104. Thus, oneor more of the fluid couplers 226 may be fluidly connected with one ormore mud pumps 144 or other sources of the kill fluid via anintermediate fluid conduit 230 (e.g., pipe, hose, etc.) extending tosuch source of the kill fluid. One or more of the fluid couplers 228 maybe fluidly connected with a kill port of the ported adapter 136 oranother port connected with the annulus 108 via an intermediate fluidconduit 232 (e.g., pipe, hose, etc.) extending to such port.Accordingly, the fluid conduits 222 may be or comprise at least portionsof emergency kill lines.

Furthermore, one or more of the fluid conduits 224 may form at least aportion of the base 208 and the ramp 210, extending between the distalend of the base 208 away from the rig floor 114 and/or the wellbore 102and a proximal end of the ramp 210 closest to the rig floor 114 and/orthe wellbore 102. One or more of the fluid conduits 224 may terminatewith a distal fluid coupler 234 and an opposing proximal fluid coupler236. The fluid conduits 224 and corresponding couplers 234, 236 may beor comprise high-pressure (e.g., rated for 15,000 PSI or more) fluidconduits and couplers configured to convey cement slurry from the groundlevel to the rig floor 114 during cementing operations at the oil andgas wellsite 104. Thus, one or more of the fluid couplers 234 may befluidly connected with one or more cement pumps (not shown) via anintermediate fluid conduit 238 (e.g., pipe, hose, etc.) extending tosuch cement pumps, which may be located at the wellsite 104 at adistance from the rig floor 114. One or more of the fluid couplers 236may be fluidly connected with a cement head 240 during cementingoperations via an intermediate fluid conduit 242 (e.g., pipe, hose,etc.) extending to such cement head 240 located above or otherwise atthe rig floor 114. Accordingly, the fluid conduits 224 may be orcomprise at least portions of cement lines. The cement head 240 may beconnected to a casing extending from the wellbore 102 and operated by ahuman operator 203 (e.g., a roughneck, a derrickman, etc.) during thecementing operations. The base 208 and the ramp 210, including the fluidconduits 222, 224, may be separate and distinct from the catwalk 206,permitting a mechanical interface with the rig floor 114 by the ramp 210and a fluid connection between mud pumps 144 and the ported adapter 136and between the cement pumps and the cement head 240 to be maintainedwhile swapping out a catwalk 206.

FIGS. 3-9 are schematic views of an example implementation of a tubularhandling catwalk system 300 according to one or more aspects of thepresent disclosure, which may be installed and utilized at or form aportion of a well construction system, such as the well constructionsystems 100, 200 shown in FIGS. 1 and 2, respectively. FIG. 3 shows aside view of the catwalk system 300 in a folded and disassembledoperational stage, FIG. 4 shows a side view of the catwalk system 300 inan unfolded and assembled operational stage, and FIG. 5 shows a sideview of the catwalk system 300 without a tubular handling catwalk. FIGS.6 and 7 show an upper and bottom views, respectively, of the catwalksystem 300 shown in FIG. 4. FIGS. 8 and 9 show proximal and distal endviews, respectively, of the catwalk system 300 shown in FIG. 4. Thecatwalk system 300 may comprise one or more features and/or perform oneor more operations of the catwalk system 202 shown in FIG. 2. Unlessreferring to a specific one or more of the FIGS. 1-9, the followingdescription refers to FIGS. 1-9, collectively.

The catwalk system 300 may comprise a catwalk suitcase 304 and a tubularhandling catwalk 306. The catwalk suitcase 304 may be configured tosupport, detachably connect with, and/or otherwise receive the tubularhandling catwalk 306. The catwalk suitcase 304 may comprise a base 308configured to be mounded or otherwise disposed on the ground level(e.g., the ground) of the oil and gas wellsite 104 and to receive thetubular handling catwalk 306. The base 308 may be configured todetachably connect with the catwalk 306 received by the base 308. Thebase 308 may also or instead be configured to support the catwalk 306thereon above the ground level of the oil and gas wellsite 104. Thecatwalk suitcase 304 may further comprise a ramp 310 (also known as aV-Door) connected with the base 308 and operable to be positioned in aninclined fashion (e.g., extending diagonally) between the base 308 andthe rig floor 114 at the oil and gas wellsite 104, as shown in FIG. 4.When the catwalk 306 is received by the base 308, the ramp 310 mayfacilitate movement of tubulars 301 (e.g., drill pipes, drill collars,casing joints, downhole tools, etc.) from the catwalk 306 to the rigfloor 114.

The base 308 may comprise a horizontal portion 314 configured to bedisposed on and extending substantially parallel to the ground level ofthe oil and gas wellsite 104, and a vertical 316 portion fixedlyconnected with the horizontal portion 314 and extending substantiallyperpendicularly with respect to the ground level of the oil and gaswellsite 104. The ramp 310 may be pivotably connected with base 308 viaa pivot joint 320 at an upper end of the vertical portion 316. Thehorizontal and vertical portions 314, 316 of the base 308 may define aspace 318 configured to receive the catwalk 306 therein. When thecatwalk 306 is received by the base 308 within the space 318, as shownin FIG. 4, an upper surface 309 of the catwalk 306 is aligned with oradjacent to a lower end of the ramp 310. Accordingly, during operations,the catwalk 306 may receive a tubular 301 into a channel or groove 382extending longitudinally along the upper surface 309 of the catwalk 306and a powered skate 321 of the catwalk 306 may be operable to push thetubular 301 along the groove 382 toward the ramp 310. After the tubular301 contacts the lower portion of the ramp 310, the skate 321 may pushthe tubular 301 upwardly along the ramp 310 toward the rig floor 114until an upper end (e.g., box end) of the tubular 301 extends above therig floor 114, as shown in FIG. 2. The tubulars 301 may be stored onand/or transferred onto the catwalk 306 via one or more tubular racks307, which may be installed on one or both sides of the catwalk 306. Forclarity and ease of understanding the tubular racks 307 are shown juston FIGS. 8 and 9.

The skate 321 may be operatively connected with or form a portion of amechanical power system 360 operable to move the tubulars 301 along thecatwalk 306 and the ramp 310. The mechanical power system 360 may be orcomprise a winch system comprising a plurality of gears or pulleys 362operable to transfer torque generated by a motor 364 to tension one ormore belts, chains, or other lines 366. The line 366 may be connectedwith the skate 321 to transfer power from the motor 364 to the skate321, thereby facilitating movement of the tubular 301. The mechanicalpower system 360 may be, for example, a fluid powered system comprisinga hydraulic motor 364 or an electrically powered system comprising anelectric motor 364.

The catwalk suitcase 304 may comprise a plurality of fluid conduits 322,324 extending longitudinally along the base 308 and/or ramp 310 betweenopposing ends of the base 308 and/or ramp 310. For example, one or morefluid conduits 322 may form at least a portion of the base 308,extending between a distal end of the base 308 away from the rig floor114 and/or wellbore 102, and a proximal end of the base 308 closest tothe rig floor 114 and/or the wellbore 102. One or more of the fluidconduits 322 may terminate with a distal fluid coupler 326 and anopposing proximal fluid coupler 328. The fluid conduits 322 may be orcomprise medium pressure (e.g., rated for 7,500 PSI or more) fluidconduits configured to convey a kill weight fluid during well killoperations at the oil and gas wellsite 104. Thus, one or more of thefluid couplers 326 may be fluidly connected with one or more mud pumps144 via an intermediate fluid conduit 230 extending to the mud pumps144. One or more of the fluid couplers 328 may be fluidly connected witha kill port of a ported adapter 136 or another port fluidly connectedwith an annulus 108 of the wellbore 102 via an intermediate fluidconduit 232 extending to such port.

Furthermore, one or more fluid conduits 324 may form at least a portionof the base 308 and the ramp 310, extending between the distal end ofthe base 308 (and the catwalk suitcase 304) away from the rig floor 114and/or wellbore 102 and a proximal end of the ramp 310 (and the catwalksuitcase 304) closest to the rig floor 114 and/or wellbore 102. One ormore of the fluid conduits 324 may terminate with a distal fluid coupler334 and an opposing proximal fluid coupler 336. The fluid conduits 324may be or comprise high-pressure (e.g., rated for 15,000 PSI or more)fluid conduits configured to convey cement slurry to the rig floor 114during cementing operations at the oil and gas wellsite 104. Thus, oneor more of the fluid couplers 334 may be fluidly connected with one ormore cement pumps (not shown) via an intermediate fluid conduit 238extending to such cement pumps, which may be located at the ground levelof the wellsite 104 at a distance from the rig floor 114. One or more ofthe fluid couplers 336 may be fluidly connected with a cement head 240during cementing operations via an intermediate fluid conduit 242extending to the cement head 240 located above or otherwise at the rigfloor 114. The fluid conduits 324 may also or instead be utilized toconvey a kill weight fluid during well kill operations at the oil andgas wellsite 104. For example, if the kill weight fluid is intended tobe conveyed to the wellbore 102 at high pressures (e.g., at 15,000 PSIor more), the cement pumps may be utilized to convey the kill weightfluid to the wellbore 102 via at least a portion of the fluid conduits324.

The fluid conduits 324 may each comprise a plurality of distinctportions (e.g., pipes, hoses, etc.) that may be disconnected fortransport, as shown in FIG. 3, and reconnected when the catwalk system300 is being installed at the wellsite 104. A portion of the fluidconduits 324 may be connected with or form a portion of the ramp 310 andanother (opposing) portion of the fluid conduits 324 may be connectedwith or form a portion of the base 308. During installation of thecatwalk system 300, the ramp 310 may be unfolded or pivoted such thatthe ramp 310 is positioned in an inclined fashion extending diagonallybetween the base 308 and the drill rig floor 114, as shown in FIG. 4.The opposing portions of the fluid conduits 324 may be fluidly coupledvia corresponding intermediate fluid conduit portions 325. The opposingportions of the fluid conduits 324 and the intermediate fluid conduitportions 325 may be fluidly connected via corresponding fluid couplers.The intermediate fluid conduit portions 325 may be or comprisehigh-pressure swivel joints (e.g., chicksan joints) or other fluidconduits (e.g., pipes, hoses, etc.). Thus, the opposing portions of thefluid conduits 324 and the intermediate fluid conduit portions 325 maycollectively form the fluid conduits 324 extending along the base 308and the ramp 310 from the ground level of the wellsite 104 to the rigfloor 114.

The catwalk suitcase 302 may further comprise additional fluid conduits327 (e.g., pipes, hoses, etc.) connected with or forming a portion ofthe ramp 310. The fluid conduits 327 may extend longitudinally betweenopposing ends of the ramp 310. The fluid conduits 327 may be connectedwith the fluid conduits 322, such as may permit fluids (e.g., cementslurry, hydraulic fluid, drilling mud, etc.) to be transferred along thefluid conduits 322, 327 between the ground level of the wellsite 104 andthe rig floor 114 instead of such fluids being transferred to the portedadapter 136 via the fluid conduits 322. The fluid conduits 327 may beconnected with the fluid conduits 322 via intermediate fluid conduits,such as the intermediate fluid conduit portions 325.

Although the catwalk suitcase 302 is shown comprising two of each of thefluid conduits 322, 324, 327, it is to be understood that the catwalksuitcase 302 may comprise other quantities of such fluid conduits 322,324, 327. For example, the catwalk suitcase 302 within the scope of thepresent disclosure may comprise one, three, four, or more of each of thefluid conduits 322, 324, 327. The quantities of each of the fluidconduits 322, 324, 327 may be determined based on, for example,configuration of the well construction system 100, 200 (e.g., quantityof kill ports, quantity of casing heads, quantity of ports in the casinghead, etc.) and/or operational parameters of the well constructionsystem 100, 200 (e.g., intended flows of the kill fluid, the cementflurry, or another fluid, etc.).

The base 308 of the catwalk suitcase 304 may be skidded or otherwisecomprise a skid 340 configured to facilitate transportation of thecatwalk suitcase 304 and/or the catwalk system 300. The skid 340 may befixedly connected with the horizontal portion 314 of the base 308 orotherwise integrated as part of the base 308. The catwalk 306 may beskidded or otherwise comprise a skid 342 configured to facilitatetransportation of the catwalk 306. The skid 342 may be fixedly connectedwith the catwalk 306 or otherwise integrated as part of the catwalk 306.The skid 340 or another portion of the base 308 may be configured to bemounded or otherwise disposed on the ground level (e.g., the ground) ofthe oil and gas wellsite 104 and to receive the skid 342 or anotherportion of the catwalk 306. The skids 340, 342 may permit the catwalksuitcase 304 and the catwalk 306, respectively, to be mounted on atrailer, such as may permit transportation to the wellsite 104 and/or tobe moved and installed at the wellsite 104. The skids 340, 342 may beconstructed pursuant to International Organization for Standardization(ISO) specifications, permitting the catwalk suitcase 304 and/or thecatwalk 306 to be transported like an intermodal ISO container.

The base 308 may be configured to support the catwalk 306 thereon abovethe ground level of the oil and gas wellsite 104. The base 308 may alsoor instead be configured to detachably connect with the skid 342 oranother portion of the catwalk 306 received by the base 308. Forexample, the base 308 and the catwalk 306 may be detachably connectedtogether via a plurality of pins or bolts 344 extending between and atleast partially through the base 308 and the catwalk 306, therebypreventing relative movement therebetween.

The base 308 of the catwalk suitcase 304 may comprise a frame assembly370 supporting or otherwise connected with the fluid conduits 322, 324extending along the frame assembly 370. The fluid conduits 322, 324 maybe connected with the frame assembly 370 via a plurality of brackets 372connected with the frame assembly 370. The skid 340 may be connectedwith or form at least a portion of the frame assembly 370. Similarly,the ramp 310 of the catwalk suitcase 304 may comprise a frame assembly374 supporting or otherwise connected with the fluid conduits 324extending along the frame assembly 374. The fluid conduits 324 may beconnected with the frame assembly 374 via a plurality of brackets 376connected with the frame assembly 374. The catwalk 306 may also comprisea frame assembly 390 supporting or otherwise connected with the uppersurface 309 and the mechanical power system 360. The skid 342 may beconnected with or form at least a portion of the frame assembly 390. Theframe assemblies 370, 374, 390 may be or comprise a plurality ofinterconnected structural steel members or beams (just a few shown inFIGS. 7 and 8 for clarity) connected with the fluid conduits 322, 324,327 and the mechanical power system 360, respectively. One or more ofthe frame assemblies 370, 374, 390 may at least partially extend aboutthe fluid conduits 322, 324, 327 and the mechanical power system 360,such as to protect the fluid conduits 322, 324, 327 and the mechanicalpower system 360 from physical damage during transport, assembly, andoperations, and to help facilitate transportation of the catwalksuitcase 304 and the catwalk 306. The frame assembly 370 may be aload-bearing frame assembly operable to support the weight of thecatwalk 306 received by the base 308. The frame assembly 374 may be aload-bearing frame assembly operable to support the weight of thetubulars 301 being moved along the ramp 310 toward the rig floor 114.

The ramp 310 may further comprise a slide 380 configured to facilitatesliding of tubulars 301 being moved from the catwalk 306 to the rigfloor 114. The slide 380 may be or comprise a low friction surfaceconfigured to facilitate movement of the tubulars 301 being pushed bythe skate 321 along the ramp 310 to the rig floor 114. For example,after a tubular 301 is received within the groove 382 of the catwalk306, the lower (i.e., pin) end of the tubular 301 may be pushed by theskate 321 causing the upper (i.e., box) end of the tubular 301 to slideupwardly along the slide 380 toward the rig floor 114. After the skate321 reaches the end of travel and the upper end of the tubular 301 is atthe rig floor 114, as shown in FIG. 2, lifting equipment, such as anelevator 129 of a top drive 116 or a pipe delivery arm (not shown), maylift the tubular 301, thereby causing the lower end of the tubular 301to slide upwardly along the slide 380. The slide 380 may furthercomprise a longitudinal groove 384 configured to center or otherwiseguide the tubular 301 while the tubular 301 slides along the slide 380.The ramp 310 may also comprise guide railings or other members 386configured to maintain the tubulars 301 along or within the slide 380 ofthe ramp 308 while the tubulars 301 are transferred along the ramp 310from the catwalk 306 to the rig floor 114.

As further shown in FIGS. 3-9, the catwalk suitcase 304 and/or thecatwalk 306 may comprise a plurality of detachably connectable portionsthat may be transported individually and connected (i.e., assembled)together at the wellsite 104 to install the catwalk system 300 at thewellsite 104 as part of the well construction system 100, 200. Forexample, the base 308 may comprise first and second base portions 346,348 that may be disconnected for transportation and connected togetherat the wellsite 104. Each base portion 346, 348 may comprisecorresponding portions of the frame assembly 370, the fluid conduits322, 324, and the skid 340. The first and second base portions 346, 348may be connected via fasteners, such as pins or bolts 350, and thecorresponding portions of the conduits 322, 324 may be connectedtogether via corresponding fluid couplers 351. The catwalk 306 maycomprise first and second portions 352, 354 that may be disconnected fortransportation and connected together at the wellsite 104. Each portion352, 354 of the catwalk 306 may comprise corresponding portions of theframe assembly 390, the skid 342, the upper surface 309, and themechanical power system 360. The first and second portions 352, 354 ofthe catwalk 306 may be connected via fasteners, such as pins or bolts356. The first and second portions 352, 354 of the catwalk 306 may alsoor instead be connected with the base 308 via the pins or bolts 344 tomaintain relative position between the first and second portions 352,354.

The catwalk suitcase 304 and the catwalk 306 may be transported whilebeing detachably connected together, as shown in FIG. 3, or catwalksuitcase 304 and the catwalk 306 may be transported separately whiledisconnected from each other. The catwalk suitcase 304 may betransported while the ramp 310 is folded or pivoted against the base 308and/or the catwalk 306, as shown in FIG. 3. During installation of thecatwalk system 300, the ramp 310 of the catwalk suitcase 304 may beunfolded or pivoted such that the ramp 310 is positioned in an inclinedfashion (e.g., extending diagonally) between the base 308 and the rigfloor 114 at the oil and gas wellsite 104, as shown in FIG. 4.Furthermore, the separated portions of the catwalk suitcase 304 and/orthe catwalk 306 may be connected together, as shown in FIGS. 4-9.Although the catwalk suitcase 304 and the catwalk 306 are shown eachcomprising two portions 346, 348 and 352, 354, respectively, that areconnectable together, it is to be understood that catwalk suitcase 304and/or the catwalk 306 may each be provided as single discrete units,wherein the portions 346, 348 of the catwalk suitcase 304 and portions352, 354 of the catwalk 306 are each integrally formed or connected and,thereby, configured to be transported to and installed at the wellsite104 as single discrete units without mandating an addition connection.

As described above, the base 308 may be configured to receive one at atime a tubular handling catwalk 306 and/or to detachably connect withthe catwalk 306 received by the base 308. Accordingly, the base 308 maybe configured to be disconnected from the received catwalk 306,permitting the catwalk 306 to be removed from the space 318, as shown inFIG. 5, and swapped or replaced by another tubular handling catwalk 306.The received catwalk 306 may be replaced by another and/or differentcatwalk 306 based on, for example, wellsite operational parameters ortype of tubulars that are intended to be moved to or from the rig floor114. The received catwalk 206 may also or instead be replaced by anothercatwalk 306 when the received catwalk 306 breaks down. Accordingly, thecatwalk 306 received by the base 308 may be a selected one of aplurality of tubular handling catwalks 306. The base 308 and the ramp310, including the fluid conduits 322, 324, may be separate and distinctfrom the catwalks 306, permitting a mechanical interface with the rigfloor 114 by the ramp 310 and a fluid connection between mud pumps 144and the ported adapter 136 and between the cement pumps and the cementhead 240 to be maintained while swapping out a catwalk 306.

The present disclosure is further directed to an example implementationof a method or operation according to one or more aspects of the presentdisclosure. The method described below and/or other operations describedherein may be performed utilizing or otherwise in conjunction with atleast a portion of one or more implementations of one or more instancesof the apparatus shown in one or more of FIGS. 1-9 and/or otherwisewithin the scope of the present disclosure. However, the method andoperations described herein may be performed in conjunction withimplementations of apparatus other than those depicted in FIGS. 1-9 thatare also within the scope of the present disclosure. Accordingly, thefollowing description refers to FIGS. 1-9, collectively.

The method may comprise installing a catwalk suitcase 304 at an oil andgas wellsite 104 such that a base 308 of the catwalk suitcase 304 isdisposed at a ground level of the oil and gas wellsite 104 and a ramp310 of the catwalk suitcase 304 extends to a drill rig floor 114 of adrill rig, detachably connecting a tubular handling catwalk 306 with thebase 308, and moving tubulars 301 from the tubular handling catwalk 306to the drill rig floor 114 via the ramp 310, as shown in FIGS. 2 and 4.

The method may further comprise disconnecting the tubular handlingcatwalk 306 from the base 308 and removing the tubular handling catwalk306 from the space 318, as shown in FIG. 5, detachably connectinganother tubular handling catwalk 306 with the base 308, and movingtubulars 301 from the another tubular handling catwalk 306 to the drillrig floor 114 via the ramp 310.

The catwalk suitcase 304 may comprise a fluid conduit 322 connected withand extending along the base 308, a fluid conduit 327 connected with andextending along the ramp 310, and/or a fluid conduit 324 connected withand extending along the base 308 and ramp 310. The method may thusfurther comprise conveying a kill weight fluid via the fluid conduit 322to a wellbore 102 at the oil and gas wellsite 104 during well killoperations, as shown in FIG. 2. The method may also or instead compriseconveying a cement slurry via the fluid conduit 327 to a cement head 240at the drill rig floor 114 during cementing operations. The method mayalso or instead comprise conveying a cement slurry via the fluid conduit324 to a cement head 240 at the drill rig floor 114 during cementingoperations, as shown in FIG. 2.

In view of the entirety of the present disclosure, including the figuresand the claims, a person having ordinary skill in the art will readilyrecognize that the present disclosure introduces an apparatuscomprising: a base configured to receive a tubular handling catwalk; anda ramp connected with the base and configured to extend diagonally to adrill rig floor located at an oil and gas wellsite, wherein the ramp isconfigured to facilitate movement of tubulars from the tubular handlingcatwalk to the drill rig floor.

The apparatus may comprise the tubular handling catwalk configured to bereceived by the base.

The tubular handling catwalk may be one of a plurality of tubularhandling catwalks, and the base may be configured to receive eachtubular handling catwalk one at a time.

The base may be configured to be disposed at ground level of the oil andgas wellsite.

The base may be configured to detachably connect with the tubularhandling catwalk.

The base may be configured to detachably connect with a skid of thetubular handling catwalk.

The base may be configured to support the tubular handling catwalkthereon.

The base may comprise: a horizontal portion configured to be disposed atground level of the oil and gas wellsite; and a vertical portion fixedlyconnected with the horizontal portion, wherein the ramp is connectedwith an upper end of the vertical portion, and wherein the horizontaland vertical portions define a space configured to receive the tubularhandling catwalk.

The base may comprise a skid configured to facilitate transportation ofthe apparatus.

The ramp may be pivotably connected with the base.

The ramp may comprise a slide configured to facilitate sliding of thetubulars from the tubular handling catwalk to the drill rig floor.

The base may comprise a frame and a fluid conduit extending along theframe. The fluid conduit may be configured to convey a kill weight fluidduring well kill operations at the oil and gas wellsite.

The ramp may comprise a frame and a fluid conduit extending along theframe of the ramp. The fluid conduit may be configured to convey acement slurry from a ground level of the oil and gas wellsite to thedrill rig floor during cementing operations at the oil and gas wellsite.

The apparatus may comprise a fluid conduit connected with and extendinglongitudinally along the base and ramp. The fluid conduit may beconfigured to convey a cement slurry from a ground level of the oil andgas wellsite to the drill rig floor during cementing operations at theoil and gas wellsite. The fluid conduit may be configured to convey akill weight fluid during well kill operations at the oil and gaswellsite.

The present disclosure also introduces an apparatus comprising a catwalksuitcase comprising: a base configured to detachably connect with atubular handling catwalk; a ramp connected with the base and configuredto extend to a drill rig floor located at an oil and gas wellsite,wherein the ramp is configured to facilitate movement of tubulars fromthe tubular handling catwalk to the drill rig floor; and a plurality offluid conduits connected with and extending along the base and/or ramp.

The apparatus may comprise the tubular handling catwalk configured todetachably connect with the base.

The tubular handling catwalk may be one of a plurality of tubularhandling catwalks, and the base may be configured to detachably connectwith each tubular handling catwalk one at a time.

The base may be configured to be disposed at ground level of the oil andgas wellsite.

The base may be configured to detachably connect with a skid of thetubular handling catwalk.

The base may be configured to support the tubular handling catwalkthereon.

The base may comprise: a horizontal portion configured to be disposed atground level of the oil and gas wellsite; and a vertical portion fixedlyconnected with the horizontal portion, wherein the ramp is connectedwith an upper end of the vertical portion, and wherein the horizontaland vertical portions define a space configured to receive the tubularhandling catwalk.

The base may comprise a skid configured to facilitate transportation ofthe catwalk suitcase.

The ramp may be pivotably connected with the base.

The ramp may comprise a slide configured to facilitate sliding of thetubulars from the tubular handling catwalk to the drill rig floor.

The base may comprise a base frame, and at least one of the fluidconduits may be connected with and extend along the base frame. The rampmay comprise a ramp frame, at least one of the fluid conduits may beconnected with and extend along the ramp frame, and at least one of thefluid conduits of the base and at least one of the fluid conduits of theramp may be connected. The at least one of the fluid conduits of thebase and the at least one of the fluid conduits of the ramp may beconfigured to convey a cement slurry during cementing operations at theoil and gas wellsite.

At least one of the fluid conduits may be configured to convey a cementslurry from ground level of the oil and gas wellsite to the drill rigfloor during cementing operations.

At least one of the fluid conduits may be configured to convey a killweight fluid during well kill operations at the oil and gas wellsite.

The present disclosure also introduces a method comprising: installing acatwalk suitcase at an oil and gas wellsite such that a base of thecatwalk suitcase is disposed at a ground level of the oil and gaswellsite and a ramp of the catwalk suitcase extends to a rig floor of adrill rig; detachably connecting a tubular handling catwalk with thebase; and moving tubulars from the tubular handling catwalk to the rigfloor via the ramp.

The method may further comprise: disconnecting the tubular handlingcatwalk from the base; detachably connecting another tubular handlingcatwalk with the base; and moving tubulars from the another catwalk tothe rig floor via the ramp.

The catwalk suitcase may comprise a fluid conduit connected with andextending along the base, and the method may further comprise conveyinga kill weight fluid via the fluid conduit during well kill operations.

The catwalk suitcase may comprise a fluid conduit connected with andextending along the ramp, and the method may further comprise conveyinga cement slurry via the fluid conduit during cementing operations.

The catwalk suitcase may comprise a fluid conduit connected with andextending along the base and the ramp, and the method may furthercomprise conveying a cement slurry via the fluid conduit duringcementing operations.

The foregoing outlines features of several implementations so that aperson having ordinary skill in the art may better understand theaspects of the present disclosure. A person having ordinary skill in theart should appreciate that they may readily use the present disclosureas a basis for designing or modifying other processes and structures forcarrying out the same functions and/or achieving the same benefits ofthe implementations introduced herein. A person having ordinary skill inthe art should also realize that such equivalent constructions do notdepart from the spirit and scope of the present disclosure, and thatthey may make various changes, substitutions, and alterations hereinwithout departing from the spirit and scope of the present disclosure.

The Abstract at the end of this disclosure is provided to comply with 37C.F.R. § 1.72(b) to permit the reader to quickly ascertain the nature ofthe technical disclosure. It is submitted with the understanding that itwill not be used to interpret or limit the scope or meaning of theclaims.

What is claimed is:
 1. An apparatus comprising: a base configured toreceive a tubular handling catwalk; and a ramp connected with the baseand configured to extend diagonally to a drill rig floor located at anoil and gas wellsite, wherein the ramp is configured to facilitatemovement of tubulars from the tubular handling catwalk to the drill rigfloor.
 2. The apparatus of claim 1 wherein the tubular handling catwalkis one of a plurality of tubular handling catwalks, and wherein the baseis configured to receive each tubular handling catwalk one at a time. 3.The apparatus of claim 1 wherein the base is configured to detachablyconnect with the tubular handling catwalk.
 4. The apparatus of claim 1wherein the base is configured to support the tubular handling catwalkthereon.
 5. The apparatus of claim 1 wherein the base comprises: ahorizontal portion configured to be disposed at ground level of the oiland gas wellsite; and a vertical portion fixedly connected with thehorizontal portion, wherein the ramp is connected with an upper end ofthe vertical portion, and wherein the horizontal and vertical portionsdefine a space configured to receive the tubular handling catwalk. 6.The apparatus of claim 1 wherein the base comprises: a frame; and afluid conduit extending along the frame.
 7. The apparatus of claim 6wherein the fluid conduit is configured to convey a kill weight fluidduring well kill operations at the oil and gas wellsite.
 8. Theapparatus of claim 1 wherein the ramp comprises: a frame; and a fluidconduit extending along the frame of the ramp.
 9. The apparatus of claim8 wherein the fluid conduit is configured to convey a cement slurry froma ground level of the oil and gas wellsite to the drill rig floor duringcementing operations at the oil and gas wellsite.
 10. The apparatus ofclaim 1 further comprising a fluid conduit connected with and extendinglongitudinally along the base and ramp.
 11. The apparatus of claim 10wherein the fluid conduit is configured to convey a cement slurry from aground level of the oil and gas wellsite to the drill rig floor duringcementing operations at the oil and gas wellsite.
 12. An apparatuscomprising: a catwalk suitcase comprising: a base configured todetachably connect with a tubular handling catwalk; a ramp connectedwith the base and configured to extend to a drill rig floor located atan oil and gas wellsite, wherein the ramp is configured to facilitatemovement of tubulars from the tubular handling catwalk to the drill rigfloor; and a plurality of fluid conduits connected with and extendingalong the base and/or ramp.
 13. The apparatus of claim 12 wherein thebase comprises: a horizontal portion configured to be disposed at groundlevel of the oil and gas wellsite; and a vertical portion fixedlyconnected with the horizontal portion, wherein the ramp is connectedwith an upper end of the vertical portion, and wherein the horizontaland vertical portions define a space configured to receive the tubularhandling catwalk.
 14. The apparatus of claim 12 wherein at least one ofthe fluid conduits is configured to convey a kill weight fluid duringwell kill operations at the oil and gas wellsite.
 15. The apparatus ofclaim 12 wherein at least one of the fluid conduits is configured toconvey a cement slurry from ground level of the oil and gas wellsite tothe drill rig floor during cementing operations.
 16. A methodcomprising: installing a catwalk suitcase at an oil and gas wellsitesuch that a base of the catwalk suitcase is disposed at a ground levelof the oil and gas wellsite and a ramp of the catwalk suitcase extendsto a rig floor of a drill rig; detachably connecting a tubular handlingcatwalk with the base; and moving tubulars from the tubular handlingcatwalk to the rig floor via the ramp.
 17. The method of claim 16further comprising: disconnecting the tubular handling catwalk from thebase; detachably connecting another tubular handling catwalk with thebase; and moving tubulars from the another catwalk to the rig floor viathe ramp.
 18. The method of claim 16 wherein the catwalk suitcasecomprises a fluid conduit connected with and extending along the base,and wherein the method further comprises conveying a kill weight fluidvia the fluid conduit during well kill operations.
 19. The method ofclaim 16 wherein the catwalk suitcase comprises a fluid conduitconnected with and extending along the ramp, and wherein the methodfurther comprises conveying a cement slurry via the fluid conduit duringcementing operations.
 20. The method of claim 16 wherein the catwalksuitcase comprises a fluid conduit connected with and extending alongthe base and the ramp, and wherein the method further comprisesconveying a cement slurry via the fluid conduit during cementingoperations.